Fluorous additives for use in a fluorous-based treatment fluid

ABSTRACT

A treatment fluid comprises: a liquid fluorinated compound; and at least one additive, wherein the additive: (A) comprises carbon and at least one fluorine functional group; and (B) is soluble or dispersible in the liquid fluorinated compound. A method of treating a portion of a well comprises: forming the treatment fluid; and introducing the treatment fluid into the well.

TECHNICAL FIELD

An additive for use in a fluorous-based treatment fluid is provided. Theadditive comprises carbon and at least one fluorine functional group.The additive is soluble or dispersible in the fluorous-based treatmentfluid. A method of treating a portion of a well is also provided.According to an embodiment, the well is an oil, gas, or water productionwell, or an injection well.

SUMMARY

According to an embodiment, a treatment fluid comprises: a liquidfluorinated compound; and at least one additive, wherein the additive:(A) comprises carbon and at least one fluorine functional group; and (B)is soluble or dispersible in the liquid fluorinated compound.

According to another embodiment, a method of treating a portion of awell comprises: forming the treatment fluid; and introducing thetreatment fluid into the well.

DETAILED DESCRIPTION OF THE INVENTION

As used herein, the words “comprise,” “have,” “include,” and allgrammatical variations thereof are each intended to have an open,non-limiting meaning that does not exclude additional elements or steps.

It should also be understood that, as used herein, “first,” “second,”and “third,” are assigned arbitrarily and are merely intended todifferentiate between two or more additives, etc., as the case may be,and does not indicate any sequence. Furthermore, it is to be understoodthat the mere use of the word “first” does not require that there be any“second,” and the mere use of the word “second” does not require thatthere be any “third,” etc.

As used herein, a “fluid” is a substance having an external phase thattends to flow and to conform to the outline of its container when thesubstance is tested at a temperature of 71° F. (22° C.) and a pressureof one atmosphere “atm” (0.1 megapascals “MPa”). A fluid can be a liquidor gas. A homogenous fluid has only one phase; whereas a heterogeneousfluid has more than one distinct phase. A solution is an example of ahomogenous fluid, containing a solvent (e.g., water) and a solute. Acolloid is an example of a heterogeneous fluid. A colloid can be: aslurry, which includes an external liquid phase and undissolved solidparticles as the internal phase; an emulsion, which includes an externalliquid phase and at least one internal phase of immiscible liquiddroplets; a foam, which includes an external liquid phase and a gas asthe internal phase; or a mist, which includes an external gas phase andliquid droplets as the internal phase. There can be more than oneinternal phase of a colloid, but only one external phase. For example,there can be an external phase which is adjacent to a first internalphase, and the first internal phase can be adjacent to a second internalphase. Any of the phases of a colloid can contain dissolved materialsand/or undissolved solids.

Oil and gas hydrocarbons are naturally occurring in some subterraneanformations. A subterranean formation containing oil or gas is sometimesreferred to as a reservoir. A reservoir may be located under land or offshore. Reservoirs are typically located in the range of a few hundredfeet (shallow reservoirs) to a few tens of thousands of feet (ultra-deepreservoirs). In order to produce oil or gas, a wellbore is drilled intoa reservoir or adjacent to a reservoir.

A well can include, without limitation, an oil, gas or water productionwell, an injection well, or a geothermal well. As used herein, a “well”includes at least one wellbore. A wellbore can include vertical,inclined, and horizontal portions, and it can be straight, curved, orbranched. As used herein, the term “wellbore” includes any cased, andany uncased, open-hole portion of the wellbore. A near-wellbore regionis the subterranean material and rock of the subterranean formationsurrounding the wellbore. As used herein, a “well” also includes thenear-wellbore region. The near-wellbore region is generally consideredto be the region within about 100 feet of the wellbore. As used herein,“into a well” means and includes into any portion of the well, includinginto the wellbore or into the near-wellbore region via the wellbore.

A portion of a wellbore may be an open hole or cased hole. In anopen-hole wellbore portion, a tubing string may be placed into thewellbore. The tubing string allows fluids to be introduced into orflowed from a remote portion of the wellbore. In a cased-hole wellboreportion, a casing is placed into the wellbore which can also contain atubing string. A wellbore can contain an annulus. Examples of an annulusinclude, but are not limited to: the space between the wellbore and theoutside of a tubing string in an open-hole wellbore; the space betweenthe wellbore and the outside of a casing in a cased-hole wellbore; andthe space between the inside of a casing and the outside of a tubingstring in a cased-hole wellbore.

During wellbore operations, it is common to introduce a treatment fluidinto the well. Examples of common treatment fluids include, but are notlimited to, drilling fluids, spacer fluids, completion fluids, work-overfluids, production enhancement fluids, such as fracturing and acidizingfluids, and packer fluids. As used herein, a “treatment fluid” is afluid designed and prepared to resolve a specific condition of a well orsubterranean formation, such as for stimulation, isolation, gravelpacking, or control of gas or water coning. The term “treatment fluid”refers to the specific composition of the fluid as it is beingintroduced into a well. The word “treatment” in the term “treatmentfluid” does not necessarily imply any particular action by the fluid.

A treatment fluid commonly includes one or more additives. Examples ofadditives commonly used include fluid loss additives, lost-circulationmaterials, corrosion inhibitors, lubricants, viscosifiers or suspendingagents, high-temperature stabilizers, sweeping agents, emulsifiers, andoxygen scavengers.

During lost circulation of a treatment fluid, the liquid portion of thefluid can enter the subterranean formation. In order to overcome theproblems associated with lost circulation, a fluid loss additive or alost-circulation material (“LCM”), can be used. LCMs are generallynon-swellable, granular-shaped substances. As the treatment fluid isplaced into the well, the fluid loss additive or the LCM can eliminateor lessen the amount of fluid entering the formation. For example, theparticles of the LCM can build upon each other and form a bridge overhighly-permeable areas of the formation. The bridge can eliminate orreduce the amount of liquid entering the formation via the wellbore.

Another common additive is a corrosion inhibitor. A corrosion inhibitorfunctions to reduce or eliminate corrosion to metal well components. Yetanother type of additive is a viscosifier or suspending agent. Aviscosifier can increase the viscosity of a treatment fluid. Viscosityis a measure of the resistance of a fluid to flow, defined as the ratioof shear stress to shear rate. Viscosity can be expressed in units of(force*time)/area. For example, viscosity can be expressed in units ofdyne*s/cm² (commonly referred to as Poise (P)), or expressed in units ofPascals/second (Pa/s). At a certain viscosity, undissolved solids can bemore uniformly suspended in the liquid portion of the fluid withoutsettling out of the liquid.

Treatment fluids are generally oil or water based. As used herein, theterm “oil based” means that the fluid comprises a hydrocarbon liquidexternal phase or is a hydrocarbon solution. As used herein, the term“water based” means that the fluid comprises an aqueous liquid externalphase or is an aqueous solution. A treatment fluid having a fluorinatedliquid phase has been shown to have improved properties over oil- andwater-based treatment fluids. Some of the improved properties includehigher thermal stability, improved lubricity, and better shalestability. One example of a fluorinated drilling fluid is disclosed inU.S. Pat. No. 7,858,564, issued to David Pasquier, Alain Driancourt, andAnnie Audibert on Dec. 28, 2010, which is hereby incorporated byreference in its entirety for all purposes. It is to be understood thatif there is any conflict in the usage of a word or term in thisspecification and one or more patent(s) or other documents that may beincorporated herein by reference, then the definitions that areconsistent with this specification should be adopted.

However, traditional additives used in oil- and water-based treatmentfluids are incompatible with fluorous-based fluids. As used herein, theterm “fluorous based” means that the fluid comprises a fluorous liquidexternal phase or is a fluorous solution. For example, the additive maynot be soluble or dispersible in a fluorous-based fluid. As used herein,the term “soluble” means that at least 1 gram (g) of the solid willdissolve in 100 g of the fluid at a temperature of 71 ° F. (21.7° C.)and a pressure of 1 atmosphere (atm). As used herein, the term“dispersible” means solid particles will separate uniformly throughout afluid upon agitation. It is to be understood that some clumping togetherof the solid particles can exist, but the majority of the solidparticles should be capable of separating uniformly throughout thefluid. A need therefore exists for treatment fluid additives that arecompatible with fluorous-based treatment fluids.

According to an embodiment, a treatment fluid comprises: a liquidfluorinated compound; and at least one additive, wherein the additive:(A) comprises carbon and at least one fluorine functional group; and (B)is soluble or dispersible in the liquid fluorinated compound.

According to another embodiment, a method of treating a portion of awell comprises: forming the treatment fluid; and introducing thetreatment fluid into the well.

It is to be understood that the discussion of preferred embodimentsregarding the treatment fluid or any ingredient in the treatment fluid,is intended to apply to the composition embodiments and the methodembodiments. Any reference to the unit “gallons” means U.S. gallons. Anydiscussion of a particular ingredient or fluid of an embodiment (e.g.,an additive) is meant to include the singular form of the ingredient orfluid and also the plural form of the ingredient or fluid, without theneed to continually refer to the ingredient or fluid in both thesingular and plural form throughout. For example, if a discussioninvolves “the additive,” it is to be understood that the discussionpertains to one additive (singular) and two or more additives (plural).

The treatment fluid can be, without limitation, a drilling fluid, spacerfluid, completion fluid, work-over fluid, production enhancement fluid(e.g., fracturing and acidizing fluid), or a packer fluid.

The treatment fluid comprises a liquid fluorinated compound. The liquidfluorinated compound comprises carbon and at least one fluorinefunctional group. The liquid fluorinated compound can also comprisemultiple fluorine functional groups. The fluorinated liquid compound cancontain other functional groups, for example, other halogenated groupsother than fluorinated, or hydrocarbon-containing groups. The liquidfluorinated compound can contain perfluorinated liquids as thefluorinated liquid, more specifically perfluoropolyalkylethers (alsoreferred to as perfluoropolyethers or PFPE) and their derivatives. PFPEsare a single class of fluorinated polymers that are liquid at ambienttemperature and have particular characteristics such as low interfacialenergy, high lubricating power, very high thermal and chemicalresistance, and low toxicity. The liquid fluorinated compound can have adensity in the range from 1,800 kilograms per cubic meter (kg/m³) to2,000 kg/m³. Commercially-available PFPE liquids include: Krytox®,available from Dupont in Wilmington, Del., USA; Fomblin®, available fromSolvay Plastics in Alpharetta, Ga., USA; and Demnum®, available fromDaikin Company in Orangeburg, N.Y., USA.

The treatment fluid can be a solution or a colloid. For a solution, theliquid fluorinated compound can be the solvent. If the treatment fluidis a solution, then the additive can be the solute. For a colloid, thetreatment fluid can be a slurry, an emulsion, or a foam. For a colloid,the liquid fluorinated compound can be the external phase of thetreatment fluid. Regardless of the type of colloid, any of the phases ofthe colloid (i.e., the external and internal phases) can containdissolved and/or undissolved ingredients. For a colloid: the additivecan be the internal phase of the colloid; the additive can be the soluteof any of the phases of the colloid; or the additive can be anundissolved solid in any of the phases of the colloid. By way ofexample, if the treatment fluid is a foam, then the external phase ofthe foam can be the liquid fluorinated compound, the additive can be asolute making up the external phase, and a gas can be the internal phaseof the foam. By way of another example, if the treatment fluid is afoam, then the external phase of the foam can be the liquid fluorinatedcompound, the additive can be an undissolved solid as a first internalphase, and a gas can be a second internal phase of the foam. By way ofyet another example, the treatment fluid can be a slurry wherein theliquid fluorinated compound is the external phase and the additive isthe internal phase.

The treatment fluid comprises the additive. The additive comprisescarbon and at least one fluorine functional group and is soluble ordispersible in the liquid fluorinated compound. The additive can alsocomprise two or more fluorine functional groups. The additive cancontain only carbon and fluorine atoms (commonly called a perfluorinatedcompound). A perfluorinated compound can also contain other atoms inaddition to carbon and fluorine. According to another embodiment, theadditive also includes other atoms in addition to carbon and fluorineatoms. For example, the additive can further comprise hydrogen, oxygen,or other atoms.

The additive can be a fluoropolymer. Fluoropolymers share the propertiesof fluorocarbons in that they are not as susceptible to the van derWaals force as hydrocarbons. This contributes to their non-stick andfriction reducing properties. Moreover, fluoropolymers are stable due tothe stability that multiple carbon-fluorine bonds add to a chemicalcompound. A polymer is a large molecule composed of repeating units,typically connected by covalent chemical bonds. A polymer is formed frommonomers. During the formation of the polymer, some chemical groups canbe lost from each monomer. The piece of the monomer that is incorporatedinto the polymer is known as the repeating unit or monomer residue. Thebackbone of the polymer is the continuous link between the monomerresidues. The polymer can also contain functional groups connected tothe backbone at various locations along the backbone. Polymernomenclature is generally based upon the type of monomer residuescomprising the polymer. A polymer formed from one type of monomerresidue is called a homopolymer. A copolymer is formed from two or moredifferent types of monomer residues. The number of repeating units of apolymer is referred to as the chain length of the polymer. The number ofrepeating units of a polymer can range from approximately 11 to greaterthan 10,000. In a copolymer, the repeating units from each of themonomer residues can be arranged in various ways along the polymerchain. For example, the repeating units can be random, alternating,periodic, or block. The conditions of the polymerization reaction can beadjusted to help control the average number of repeating units (theaverage chain length) of the polymer. As used herein, a “polymer” caninclude a cross-linked polymer. As used herein, a “cross link” or “crosslinking” is a connection between two polymer molecules. A cross-linkbetween two polymer molecules can be formed by a direct interactionbetween the polymer molecules, or conventionally, by using across-linking agent that reacts with the polymer molecules to link thepolymer molecules.

A polymer has an average molecular weight, which is directly related tothe average chain length of the polymer. The average molecular weight ofa polymer has an impact on some of the physical characteristics of apolymer, for example, its solubility and its dispersibility. For acopolymer, each of the monomers will be repeated a certain number oftimes (number of repeating units). The average molecular weight for acopolymer can be expressed as follows:Avg. molecular weight=(M.W.m ₁ *RU m ₁)+(M.W.m ₂ *RU m ₂). . .

where M.W.m₁ is the molecular weight of the first monomer; RU m₁ is thenumber of repeating units of the first monomer; M.W.m₂ is the molecularweight of the second monomer; and RU m₂ is the number of repeating unitsof the second monomer. Of course, a terpolymer would include threemonomers, a tetra polymer would include four monomers, and so on.According to an embodiment, the fluoropolymer has a molecular weightsuch that the additive is soluble or dispersible in the liquidfluorinated compound.

The fluoropolymer can be a homopolymer or a copolymer. Of course thefluoropolymer can also be a cross-linked polymer. According to anembodiment, the fluoropolymer is a random, alternating, periodic, orblock copolymer. The monomer residue(s) used to form the fluoropolymercan be selected from the group consisting of ethylene, propylene, vinylfluoride, vinylidene fluoride, tetrafluoroethylene (TFE),hexafluoropropylene (HFP), perfluoropropylvinylether (PPVE),perfluoromethylvinylether (PMVE), chlorotrifluoroethylene (CTFE),polytetrafluoroethylene (PTFE), and any combination thereof. Thefluoropolymer can also contain other monomer residues not specificallylisted above.

The additive can be selected from the group consisting ofperfluoropolystyrene, perfluoropolytert-butylstyrene,perfluoropolymethylstyrene acrylates, polytetrafluoroethylene (PTFE),perfluorinated polystyrene, perfluoropolyalkylethyl acrylates,perfluoropolyalkylethyl methacrylates, perfluoropolyalkyl acrylates,perfluorinated polyamides, fluorinated polyamides,perfluoropolyacrylamides, PTFE-polyamides, perfluorinated tall oil fattyamides, fluorinated polysaccharides, perfluorinated fatty acids,perfluorinated tall oil fatty acids, perfluoropolystyrenebutadienes,perfluoropolyethylene ethene/butene copolymer, PTFE fibers, fluorinatedfibers, perfluorinated resins, fluorinated telomers, fluorinated telomeralcohols, fluorinated elastomers, tetrafluoropropanol,octafluoropentanol, dodecafluoroheptanol, derivatives of any of theforegoing, and combinations thereof.

The treatment fluid can also contain two or more additives. By way ofexample, the treatment fluid can contain a first additive and a secondadditive. Of course the treatment fluid can also contain a third,fourth, and so on additive. The additives can be different. For example,the first additive can be a fluorinated polysaccharide and the secondadditive can be tetrafluoro propanol.

The additive can be a fluid loss additive, lost-circulation material,corrosion inhibitor, lubricant, viscosifier or suspending agent,sweeping agent, emulsifier, or oxygen scavenger. The chemical structureof the additive can be selected depending on the type of additive. Thefollowing examples are given to illustrate possible chemical structuresfor the type of additive. The following examples are not the onlyexamples that could be given for a particular type of additive and arenot meant to limit the scope of the invention.

For a fluid loss additive—perfluoropolystyrene,perfluoropolytert-butylstyrene, perfluoropolymethylstyrene acrylates,polytetrafluoroethylene (PTFE), perfluoropolyalkylethyl acrylates,perfluoropolyalkylethyl methacrylates, perfluoropolyalkyl acrylates,perfluorinated polyamides, perfluoropolyacrylamides, PTFE-polyamides,fluorinated polyamides, perfluorinated tall oil fatty amides,perfluoropolystyrenebutadienes, and perfluoropolyethylene ethene/butenecopolymer. For a corrosion inhibitor—perfluoropolystyrene,perfluoropolytert-butylstyrene, perfluoropolymethylstyrene acrylates,and polytetrafluoroethylene (PTFE). For alubricant—perfluoropolystyrene, perfluoropolytert-butylstyrene,perfluoropolymethylstyrene acrylates, polytetrafluoroethylene (PTFE),perfluorinated polystyrene, PTFE fibers, fluorinated fibers,perfluorinated resins, and fluorinated telomers. For a viscosifier orsuspending agent—perfluorinated polyamides, perfluoropolyacrylamides,PTFE-polyamides, fluorinated polyamides, perfluorinated tall oil fattyamides, fluorinated polysaccharides, perfluorinated fatty acids,perfluorinated tall oil fatty acids, perfluoropolystyrenebutadienes, andperfluoropolyethylene ethene/butene copolymer. For a lost-circulationmaterial and sweeping agent—PTFE fibers, fluorinated fibers,PTFE-polyamides, fluorinated polyamides, perfluorinated resins, andfluorinated telomers. For an emulsifier—fluorinated telomer alcohols,tetrafluoropropanol, octafluoropentanol, and dodecafluoroheptanol.

According to an embodiment, the concentration of the additive isselected such that the additive functions for the intended purpose. Byway of example, the functionality of a corrosion inhibitor is generallymeasured by the amount of corrosion loss to a metal or metal alloy inunits of mils per year (mpy). A corrosion inhibitor that yields acorrosion loss of less than or equal to 50 mpy at a specific temperatureand pressure is considered to function effectively as a corrosioninhibitor. According to this example, the additive can be in at least asufficient concentration such that the treatment fluid yields acorrosion loss of less than or equal to 50 mpy at a specific temperatureand pressure. By way of another example, the functionality of a fluidloss additive is generally measured by the API or HPHT fluid loss inunits of milliliters per 30 minutes (mL/30 min). According to thisexample, the additive can be in at least a sufficient concentration suchthat treatment fluid has an API or HPHT fluid loss of less than 150mL/30 min at a specific temperature and pressure. By way of yet anotherexample, the functionality of a lost-circulation material is generallymeasured by the sealing pressure of the material in units of poundsforce per square inch (psi). According to this example, the additive canbe in at least a sufficient concentration such that additive has asealing pressure of at least 30 psi (0.2 megapascals “MPa”).

The treatment fluid can include additional additives including, but notlimited to, a high-temperature stabilizer, a pH buffer, a weightingagent, an acid, proppant, an alkalinity source, a shale stabilizer, abiocide, a scavenger, a surfactant, a thinner, a flocculent, adeflocculent, a bridging agent, a breaker, and a dispersant. The exactadditional additives that can be included depends on the type oftreatment fluid being introduced into the well. For example, a drillingfluid might further include a weighting agent, an acidizing fluid mightfurther include an acid, and a fracturing fluid might further includeproppant.

The treatment fluid can further include a high-temperature stabilizer.The high-temperature stabilizer can be selected from the groupconsisting of alkylene diamines, arylamines, benzimidazole,phenyl-β-naphthylamine, triphenylimidazole, triphenylphosphine sulfide,tetraphenylhydrazine, tetraphenyltetrazocine,perfluorotriphenylphosphine, phenothiazine, phenyl diselenide,perfluoroalkylether phosphines, diphosphatetraazacyclooctatetraenes,monodiphospha-s-triazines, diphospha-s-triazenes, derivatives of any ofthe foregoing, and any combination thereof. According to an embodiment,the treatment fluid further includes the high-temperature stabilizerwhen the bottomhole temperature of the well is greater than 302° F.(150° C.). As used herein, the term “bottomhole” means the portion ofthe well to be treated. According to another embodiment, the treatmentfluid further includes the high-temperature stabilizer when thetreatment fluid is likely to come in contact with a metal or metaloxide.

The treatment fluid can include a pH buffer. The pH buffer can beselected from the group consisting of magnesium oxide, potassiumhydroxide, calcium oxide, and calcium hydroxide. Commercially-availableexamples of a pH buffer include BARABUF®, marketed by Halliburton EnergyServices, Inc.

The treatment fluid can further include a weighting agent. The weightingagent can be selected from the group consisting of barite, hematite,manganese tetroxide, calcium carbonate, and combinations thereof.Commercially-available examples of a suitable weighting agent include,but are not limited to, BAROID®, BARACARB®, BARODENSE®, MICROMAX™, andcombinations thereof, marketed by Halliburton Energy Services, Inc.

The methods include the step of forming the treatment fluid. Thetreatment fluid can be formed ahead of use or on the fly. The methodsinclude the step of introducing the treatment fluid into the well. Themethods can further include the step of introducing a second, third, andso on treatment fluid into the well. The step of introducing cancomprise pumping the treatment fluid into the well. The well can be,without limitation, an oil, gas, or water production well, or aninjection well. The step of introducing can include introducing thetreatment fluid into an annulus. According to an embodiment, the wellpenetrates a reservoir or is located adjacent to a reservoir. Themethods can further include the step of removing at least a portion ofthe treatment fluid after the step of introducing.

The exemplary fluids and additives disclosed herein may directly orindirectly affect one or more components or pieces of equipmentassociated with the preparation, delivery, recapture, recycling, reuse,and/or disposal of the disclosed fluids and additives. For example, thedisclosed fluids and additives may directly or indirectly affect one ormore mixers, related mixing equipment, mud pits, storage facilities orunits, fluid separators, heat exchangers, sensors, gauges, pumps,compressors, and the like used to generate, store, monitor, regulate,and/or recondition the exemplary fluids and additives. The disclosedfluids and additives may also directly or indirectly affect anytransport or delivery equipment used to convey the fluids and additivesto a well site or downhole such as, for example, any transport vessels,conduits, pipelines, trucks, tubulars, and/or pipes used to fluidicallymove the fluids and additives from one location to another, any pumps,compressors, or motors (e.g., topside or downhole) used to drive thefluids and additives into motion, any valves or related joints used toregulate the pressure or flow rate of the fluids, and any sensors (i.e.,pressure and temperature), gauges, and/or combinations thereof, and thelike. The disclosed fluids and additives may also directly or indirectlyaffect the various downhole equipment and tools that may come intocontact with the fluids and additives such as, but not limited to, drillstring, coiled tubing, drill pipe, drill collars, mud motors, downholemotors and/or pumps, floats, MWD/LWD tools and related telemetryequipment, drill bits (including roller cone, PDC, natural diamond, holeopeners, reamers, and coring bits), sensors or distributed sensors,downhole heat exchangers, valves and corresponding actuation devices,tool seals, packers and other wellbore isolation devices or components,and the like.

Therefore, the present invention is well adapted to attain the ends andadvantages mentioned as well as those that are inherent therein. Theparticular embodiments disclosed above are illustrative only, as thepresent invention may be modified and practiced in different butequivalent manners apparent to those skilled in the art having thebenefit of the teachings herein. Furthermore, no limitations areintended to the details of construction or design herein shown, otherthan as described in the claims below. It is, therefore, evident thatthe particular illustrative embodiments disclosed above may be alteredor modified and all such variations are considered within the scope andspirit of the present invention. While compositions and methods aredescribed in terms of “comprising,” “containing,” or “including” variouscomponents or steps, the compositions and methods also can “consistessentially of” or “consist of” the various components and steps.Whenever a numerical range with a lower limit and an upper limit isdisclosed, any number and any included range falling within the range isspecifically disclosed. In particular, every range of values (of theform, “from about a to about b,” or, equivalently, “from approximately ato b,”) disclosed herein is to be understood to set forth every numberand range encompassed within the broader range of values. Also, theterms in the claims have their plain, ordinary meaning unless otherwiseexplicitly and clearly defined by the patentee. Moreover, the indefinitearticles “a” or “an”, as used in the claims, are defined herein to meanone or more than one of the element that it introduces. If there is anyconflict in the usages of a word or term in this specification and oneor more patent(s) or other documents that may be incorporated herein byreference, the definitions that are consistent with this specificationshould be adopted.

What is claimed is:
 1. A treatment fluid comprising: a liquid fluorinated compound; and at least one additive, wherein the additive: (A) comprises carbon and at least one fluorine functional group; (B) is soluble or dispersible in the liquid fluorinated compound; and (C) is selected from the group consisting of perfluoropolystyrene, perfluoropolytert-butylstyrene, perfluorinated polystyrene, perfluorinated polyamides, fluorinated polyamides, perfluoropolyacrylamides, perfluorinated tall oil fatty amides, fluorinated polysaccharides, perfluoropolystyrenebutadienes, and combinations thereof, wherein the liquid fluorinated compound includes at least one other halogenated functional group other than a fluorine functional group.
 2. The fluid according to claim 1, wherein the liquid fluorinated compound comprises a perfluorinated liquid compound.
 3. The fluid according to claim 1, wherein the treatment fluid is a solution.
 4. The fluid according to claim 3, wherein the liquid fluorinated compound is the solvent and the additive is the solute.
 5. The fluid according to claim 1, wherein the treatment fluid is a colloid.
 6. The fluid according to claim 5, wherein the treatment fluid is a slurry, an emulsion, or a foam.
 7. The fluid according to claim 6, wherein the liquid fluorinated compound is the external phase of the treatment fluid, and wherein the additive is the internal phase of the colloid; the solute of any of the phases of the colloid; or is an undissolved solid in any of the phases of the colloid.
 8. The fluid according to claim 1, wherein the additive comprises two or more fluorine functional groups.
 9. The fluid according to claim 1, wherein the treatment fluid comprises two or more additives.
 10. The fluid according to claim 1, wherein the additive is a fluid loss additive, lost-circulation material, corrosion inhibitor, lubricant, viscosifier or suspending agent, sweeping agent, emulsifier, or oxygen scavenger.
 11. The fluid according to claim 1, wherein the treatment fluid further comprises at least one additional additive.
 12. The fluid according to claim 11, wherein the at least one additional additive is a high-temperature stabilizer, a pH buffer, a weighting agent, an acid, proppant, an alkalinity source, a shale stabilizer, a biocide, a scavenger, a surfactant, a thinner, a flocculent, a deflocculent, a bridging agent, a breaker, and a dispersant.
 13. The fluid according to claim 12, wherein the high-temperature stabilizer is selected from the group consisting of alkylene diamines, arylamines, benzimidazole, phenyl-.beta.-naphthylamine, triphenylimidazole, triphenylphosphine sulfide, tetraphenylhydrazine, tetraphenyltetrazocine, perfluorotriphenylphosphine, phenothiazine, phenyl diselenide, perfluoroalkylether phosphines, diphosphatetraazacyclooctatetraenes, monodiphospha-s-triazines, diphospha-s-triazenes, derivatives of any of the foregoing, and any combination thereof.
 14. A treatment fluid comprising: a liquid fluorinated compound, wherein the liquid fluorinated compound comprises carbon and at least one fluorine functional group; and at least one additive, wherein the additive: (A) comprises carbon and at least one fluorine functional group; (B) is soluble or dispersible in the liquid fluorinated compound; (C) is a fluoropolymer; and (D) wherein a monomer residue used to form the fluoropolymer is selected from the group consisting of vinyl fluoride, vinylidene fluoride, perfluoropropylvinylether (PPVE), perfluoromethylvinylether (PMVE), chlorotrifluoroethylene (CTFE), and any combination thereof, wherein the liquid fluorinated compound includes at least one other halogenated functional group other than a fluorine functional group.
 15. A treatment fluid of claim 14, wherein the treatment fluid is a drilling fluid, spacer fluid, completion fluid, work-over fluid, production enhancement fluid, or a packer fluid.
 16. The treatment fluid of claim 14, wherein the monomer residue used to form the fluoropolymer is vinyl fluoride. 